<PAGE>   1
                                  UNITED STATES
                       SECURITIES AND EXCHANGE COMMISSION
                             WASHINGTON, D.C. 20549

                                    FORM 10-K


            [X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
                         SECURITIES EXCHANGE ACT OF 1934
                   For the Fiscal Year Ended December 31, 2000

                                       OR

          [ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
                         SECURITIES EXCHANGE ACT OF 1934
   For the Transition Period from ___________________ to _____________________


                         Commission File Number 0-13546


                     APACHE OFFSHORE INVESTMENT PARTNERSHIP

         A Delaware                                          IRS Employer
         General Partnership                               No. 41-1464066

                              One Post Oak Central
                       2000 Post Oak Boulevard, Suite 100
                            Houston, Texas 77056-4400

                         Telephone Number (713) 296-6000


        SECURITIES REGISTERED PURSUANT TO SECTION 12(b) OF THE ACT: NONE


           SECURITIES REGISTERED PURSUANT TO SECTION 12(g) OF THE ACT:
                                PARTNERSHIP UNITS


         Indicate by check mark whether the Partnership (1) has filed all
reports required to be filed by Section 13 or 15(d) of the Securities Exchange
Act of 1934 during the preceding 12 months (or for such shorter period that the
Partnership was required to file such reports), and (2) has been subject to such
filing requirements for the past 90 days.

                               YES    X         NO
                                     ---             ---

         Indicate by check mark if disclosure of delinquent filers pursuant to
Item 405 of Regulation S-K is not contained herein, and will not be contained,
to the best of Partnership's knowledge, in definitive proxy or information
statements incorporated by reference in Part III of this Form 10-K or any
amendment to this Form 10-K.     X
                                ---


                      DOCUMENTS INCORPORATED BY REFERENCE:

         Portions of Apache Corporation's proxy statement relating to its 2001
annual meeting of shareholders have been incorporated by reference into Part III
hereof.



<PAGE>   2

                                TABLE OF CONTENTS

                                   DESCRIPTION


<TABLE>
<CAPTION>
ITEM                                                                                                             PAGE
----                                                                                                             ----
<S>           <C>                                                                                                <C>
                                                        PART I
   1.         BUSINESS......................................................................................       1
   2.         PROPERTIES....................................................................................       4
   3.         LEGAL PROCEEDINGS.............................................................................       4
   4.         SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS...........................................       4


                                                        PART II

   5.         MARKET FOR THE PARTNERSHIP'S SECURITIES AND RELATED
                   SECURITY HOLDER MATTERS..................................................................       5
   6.         SELECTED FINANCIAL DATA.......................................................................       5
   7.         MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
                   CONDITION AND RESULTS OF OPERATIONS......................................................       6
  7A.         MARKET RISK...................................................................................       9
   8.         FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA...................................................      10
   9.         CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON
                   ACCOUNTING AND FINANCIAL DISCLOSURE......................................................      24


                                                       PART III

  10.         DIRECTORS AND EXECUTIVE OFFICERS OF THE PARTNERSHIP...........................................      24
  11.         EXECUTIVE COMPENSATION........................................................................      24
  12.         SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
                   AND MANAGEMENT...........................................................................      24
  13.         CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS................................................      24


                                                        PART IV

  14.         EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K...............................      25
</TABLE>


         All defined terms under Rule 4-10(a) of Regulation S-X shall have their
statutorily-prescribed meanings when used in this report. Quantities of natural
gas are expressed in this report in terms of thousand cubic feet (Mcf), million
cubic feet (MMcf) or billion cubic feet (Bcf). Oil is quantified in terms of
barrels (bbls), thousands of barrels (Mbbls) and millions of barrels (MMbbls).
Natural gas is compared to oil in terms of barrels of oil equivalent (boe) or
million barrels of oil equivalent (MMboe). Oil and natural gas liquids are
compared with natural gas in terms of million cubic feet equivalent (MMcfe) and
billion cubic feet equivalent (Bcfe). One barrel of oil is the energy equivalent
of six Mcf of natural gas. Daily oil and gas production is expressed in terms of
barrels of oil per day (bopd) and thousands of cubic feet of gas per day (Mcfd),
respectively. With respect to information relating to the Partnership's working
interest in wells or acreage, "net" oil and gas wells or acreage is determined
by multiplying gross wells or acreage by the Partnership's working interest
therein. Unless otherwise specified, all references to wells and acres are
gross.



<PAGE>   3

                                     PART I


ITEM 1. BUSINESS

GENERAL

     Apache Offshore Investment Partnership (the Investment Partnership), a
Delaware general partnership, was organized in October 1983, with public
investors as Investing Partners and Apache Corporation (Apache), a Delaware
corporation, as Managing Partner. The operations of the Investment Partnership
are conducted by Apache Offshore Petroleum Limited Partnership (the Limited
Partnership), a Delaware limited partnership, of which Apache is the sole
general partner and the Investment Partnership is the sole limited partner.

     The Investing Partners purchased Units of Partnership Interests (Units) in
the Investment Partnership at $150,000 per Unit, with five percent down and the
balance in payments as called by the Investment Partnership. As of December 31,
2000, a total of $85,000 had been called for each Unit. In 1989, the Investment
Partnership determined that the full $150,000 per Unit was not needed, fixed the
total calls at $85,000 per Unit, and released the Investing Partners from
liability for future calls. The Investment Partnership invested, and will
continue to invest, its entire capital in the Limited Partnership. As used
hereafter, the term "Partnership" refers to either the Investment Partnership or
the Limited Partnership, as the case may be.

     The Partnership's business is participation in oil and gas exploration,
development and production activities on federal lease tracts in the Gulf of
Mexico, offshore Louisiana and Texas. Except for the Matagorda Island Block 681
and 682 interests, as described below, the Partnership acquired its oil and gas
interests through the purchase of 85 percent of the working interests held by
Apache as a participant in a venture (the Venture) with Shell Oil Company
(Shell) and certain other companies. The Partnership owns working interests
ranging from 6.29 percent to 9.44 percent in the Venture's properties.

     The Venture acquired substantially all of its oil and gas properties
through bidding for leases offered by the federal government. The Venture
members relied on Shell's knowledge and expertise in determining bidding
strategies for the acquisitions. When Shell was successful in obtaining the
properties, it generally billed participating members on a promoted basis
(one-third for one-quarter) for the acquisition of exploratory leases and on a
straight-up basis for the acquisition of leases defined as drainage tracts. All
such billings were proportionately reduced to each member's working interest.

     In November 1992, Apache and the Partnership formed a joint venture to
acquire Shell's 92.6 percent working interest in Matagorda Island Blocks 681 and
682 pursuant to a jointly-held contractual preferential right to purchase.
Apache and the Partnership previously owned working interests in the blocks
equal to 1.109 percent and 6.287 percent, respectively, and net revenue
interests of .924 percent and 5.239 percent, respectively. To facilitate the
acquisition, Apache and the Partnership contributed all of their interests in
Matagorda Island Blocks 681 and 682 to a newly formed joint venture, and Apache
contributed $64.6 million ($55.6 million net of purchase price adjustments) to
the joint venture to finance the acquisition. The Partnership had neither the
cash nor additional financing to fund its proportionate share of the acquisition
and participated through an increased net revenue interest in the joint venture.

     Under the terms of the joint venture agreement, the Partnership's effective
net revenue interest in the Matagorda Island Block 681 and 682 properties
increased to 13.284 percent as a result of the acquisition, while its working
interest was unchanged. The acquisition added approximately 7.5 Bcf of natural
gas and 16 Mbbls of oil to the Partnership's reserve base without any
incremental expenditures by the Partnership.

     Since the Venture is not expected to acquire any additional exploratory
acreage, future acquisitions, if any, will be confined to those leases defined
as drainage tracts. The current Venture members would pay their proportionate
share of acquiring any drainage tracts on a non-promoted basis.



                                       1
<PAGE>   4

     Offshore exploration differs from onshore exploration in that production
from a prospect generally will not commence until a sufficient number of
productive wells have been drilled to justify the significant costs associated
with construction of a production platform. Exploratory wells usually are
drilled from mobile platforms until there are sufficient indications of
commercial production to justify construction of a permanent production
platform.

     Apache, as Managing Partner, manages the Partnership's operations. Apache
uses a portion of its staff and facilities for this purpose and is reimbursed
for actual costs paid on behalf of the Partnership, as well as for general,
administrative and overhead costs properly allocable to the Partnership.

2000 BUSINESS DEVELOPMENT

     During 2000, the Partnership participated in three sidetrack wells at South
Timbalier Block 295 which were completed as producers, and a development well at
Matagorda Island Block 681/682 which was a dry hole. The Partnership also
completed as a producer a development well that was spud in December 1999 at
South Timbalier Block 295. A compressor on a platform at Matagorda Island Block
681/682 was modified during 2000 to increase recoverable reserves from the
field. The Partnership continued to participate in recompletion projects,
primarily at South Timbalier Block 295, to maintain production and enhance
recoverable reserves.

     Since inception, the Partnership has acquired an interest in 49 prospects.
As of December 31, 2000, 42 of those prospects have been surrendered or sold.
During 2000, the Partnership relinquished its interest in 5,760 gross
undeveloped acres at North Padre Island Block 975.

     The status of the Partnership's 49 original prospects is shown in the
following table:

<TABLE>
<CAPTION>
                                     AS OF DECEMBER 31,
                                    -------------------
                                      2000       1999
                                    --------   --------
<S>                                 <C>        <C>
Prospect Status

Producing - developed                      7          6
Producing - partially undeveloped         --          1
                                    --------   --------

Total discoveries                          7          7
Surrendered/sold                          42         42
                                    --------   --------

Total                                     49         49
                                    ========   ========
</TABLE>

     As of December 31, 2000, 121 wells have been drilled on the seven remaining
prospects. Of the 121 wells, 95 were productive and of those, 57 are currently
producing. Fifteen of the Partnership's producing wells are dual completions.
The Partnership had, at December 31, 2000, estimated proved oil and gas reserves
of 13.4 Bcfe, of which 60 percent was natural gas.


FULL COST CEILING TEST

     Under the full cost accounting rules of the Securities and Exchange
Commission (SEC), the Partnership reviews the carrying value of its oil and gas
properties each quarter. Under these rules, capitalized costs of proved oil and
gas properties, net of accumulated depreciation, depletion and amortization, may
not exceed the present value of estimated future net cash flows from proved oil
and gas reserves, discounted at 10 percent, plus the lower of cost or fair
market value of unproved properties included in the costs being amortized, if
any. Application of these rules generally requires pricing future production at
the unescalated oil and gas prices in effect at the end of each fiscal quarter
and requires a write-down if the "ceiling" is exceeded, even if prices declined
for only a short period of time. The Partnership had no write-downs during 2000,
1999 or 1998 due to ceiling test limitations.


MARKETING

     Apache, on behalf of the Partnership, seeks and negotiates oil and gas
marketing arrangements with various marketers and purchasers. During 2000, the
Partnership's spot market gas was purchased primarily by Cinergy Marketing and
Trading, LLC. The Partnership's oil and condensate production during 2000 was
purchased largely by



                                       2
<PAGE>   5

Apache Crude Oil Marketing, Inc. (ACOM), a wholly-owned subsidiary of Apache,
and by Williams Energy Marketing & Trading Company.

     In June 1998, Apache formed a strategic alliance with Cinergy Corp.
(Cinergy) to market substantially all of Apache's natural gas production from
North America and sold its 57 percent interest in Producers Energy Marketing LLC
(ProEnergy) to Cinergy. ProEnergy, renamed Cinergy Marketing & Trading, LLC,
will continue to market Apache's North American natural gas production for 10
years, with an option to terminate after six years, under an amended and
restated gas purchase agreement effective July 1, 1998. The prices the
Partnership received for its gas production prior to the sale of ProEnergy were,
in the opinion of Apache, comparable to the prices that would have been received
from a non-affiliated party. The prices the Partnership received after the sale
of ProEnergy and will continue to receive for its gas production, in the opinion
of Apache, approximate market prices.

     During 2000, ACOM purchased oil and condensate from the Partnership which
accounted for approximately 12 percent of the Partnership's total oil and gas
sales. The prices the Partnership received for these sales were based on
third-party pricing indexes and, in the opinion of Apache, were comparable to
prices that would have been received from a non-affiliated party.

     See Note (5) "Major Customer Information" to the Partnership's financial
statements under Item 8. Because the Partnership's oil and gas products are
commodities and the prices and terms of its sales reflect those of the market,
the Partnership does not believe that the loss of any customer would have a
material adverse affect on the Partnership's business or results of operations.
The Partnership is not in a position to predict future oil and gas prices.

ENVIRONMENTAL

     The Partnership, as an owner or lessee of interests in oil and gas
properties, is subject to various federal, state and local laws and regulations
relating to the discharge of materials into, and protection of, the environment.
These laws and regulations may, among other things, impose liability on the
lessee under an oil and gas lease for the cost of pollution clean-up resulting
from operations, subject the lessee to liability for pollution damages and
require suspension or cessation of operations in affected areas.

     The Partnership has made and will continue to make expenditures in its
efforts to comply with these requirements. These costs are inextricably
connected to normal operating expenses such that the Partnership is unable to
separate the expenses related to environmental matters; however, the Partnership
does not believe such expenditures are material to its financial position or
results of operations.

     The Partnership does not believe that compliance with federal, state or
local provisions regulating the discharge of materials into the environment, or
otherwise relating to the protection of the environment, will have a material
adverse effect upon the capital expenditures, earnings and the competitive
position of the Partnership, but there is no assurance that changes in or
additions to laws or regulations regarding the protection of the environment
will not have such an impact.

COMPETITION

     The Partnership is a very minor factor in the oil and gas industry in the
Gulf of Mexico area and faces strong competition from much larger producers for
the marketing of its oil and gas. The Partnership's ability to compete for
purchasers and favorable marketing terms will depend on the general demand for
oil and gas from Gulf of Mexico producers. More particularly, it will depend
largely on the efforts of Apache to find the best markets.



                                       3
<PAGE>   6

ITEM 2. PROPERTIES

     Acreage is held by the Partnership pursuant to the terms of various leases.
The Partnership does not anticipate any difficulty in retaining any of its
desirable leases. A summary of the Partnership's producing wells and gross
acreage as of December 31, 2000, is set forth below:


<TABLE>
<CAPTION>
                                                                      PRODUCING
                                                                    OIL/GAS WELLS          AVERAGE         GROSS
                                                                 --------------------      WORKING       DEVELOPED
         LEASE BLOCK                  PROSPECT        STATE       GROSS        NET        INTEREST         ACRES
-------------------------------    ---------------   --------    --------    --------   -------------   ------------
<S>                                <C>               <C>         <C>         <C>        <C>             <C>
Ship Shoal 258, 259                Genesis             LA            9          .6         .0628698         10,141
South Timbalier 276, 295, 296      Grover              LA           24         1.7         .0708333         15,000
North Padre Island 969, 976        Rosita              TX            8          .6         .0708333         10,080
Matagorda Island 681, 682          Roberto             TX            9          .6         .0628698         10,080
South Pass 83                      Manx                LA            4          .3         .0678914          5,000
East Cameron 60                    East Aragonite      LA            1          .1         .0944444          5,000
Ship Shoal 201, 202                Bromeliad           LA            2          --             ORRI         10,000
                                                                 --------    --------                   ------------

                                                                    57         3.9                          65,301
                                                                 ========    ========                   ============
</TABLE>

     At December 31, 2000, the Partnership did not have an interest in any
undeveloped acreage.

PRODUCTION AND PRICING DATA

     The following table describes, for each of the last three fiscal years, oil
and gas production for the Partnership, average production costs (excluding
severance taxes) and average sales prices.

<TABLE>
<CAPTION>
                                     PRODUCTION                                      AVERAGE SALES PRICES
                              --------------------------         AVERAGE          ---------------------------
            YEAR ENDED            OIL           GAS            PRODUCTION             OIL             GAS
           DECEMBER 31,         (MBBLS)        (MMCF)         COST PER MCFE        (PER BBL)       (PER MCF)
          --------------      ----------     -----------     ----------------     -----------     -----------
<S>                           <C>            <C>             <C>                  <C>             <C>
              2000                 119            2,320          $     .18        $   30.16       $     3.81
              1999                 122            2,938                .18            18.10             2.15
              1998                 106            3,127                .27            12.40             2.08
</TABLE>

     See the Supplemental Oil and Gas Disclosures under Item 8 for estimated
proved oil and gas reserves quantities.


ITEM 3. LEGAL PROCEEDINGS

     There are no material legal proceedings pending to which the Partnership is
a party or to which the Partnership's interests are subject.


ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS

     There were no matters submitted to a vote of security holders during the
fourth quarter of 2000.



                                       4
<PAGE>   7

                                     PART II


ITEM 5. MARKET FOR THE PARTNERSHIP'S SECURITIES AND RELATED SECURITY HOLDER
        MATTERS

     As of December 31, 2000, there were 1,128.5 of the Partnership's Units
outstanding held by 926 investors of record. The Partnership has no other class
of security outstanding or authorized. The Units are not traded on any security
market. Cash distributions to Investing Partners totaled approximately $6.5
million, or $5,750 per Unit, during 2000 and approximately $4 million, or $3,500
per Unit, during 1999.

     As discussed in Item 7, an amendment to the Partnership Agreement in
February 1994 created a right of presentment under which all Investing Partners
have a limited and voluntary right to offer their Units to the Partnership twice
each year to be purchased in cash.


ITEM 6. SELECTED FINANCIAL DATA

     The following selected financial data for the five years ended December 31,
2000, should be read in conjunction with the Partnership's financial statements
and related notes included under Item 8.

<TABLE>
<CAPTION>
                                                AS OF OR FOR THE YEAR ENDED DECEMBER 31,
                                          ----------------------------------------------------
                                            2000       1999       1998       1997       1996
                                          --------   --------   --------   --------   --------
                                                 (In thousands, except per Unit amounts)
<S>                                       <C>        <C>        <C>        <C>        <C>
Total assets                              $  8,715   $  8,722   $  9,841   $ 10,524   $ 12,252
                                          ========   ========   ========   ========   ========

Long-term debt                            $     --   $     --   $     --   $     --   $  1,998
                                          ========   ========   ========   ========   ========

Partners' capital                         $  7,728   $  7,755   $  9,080   $  8,647   $  8,498
                                          ========   ========   ========   ========   ========

Oil and gas sales                         $ 12,417   $  8,521   $  7,827   $ 12,067   $ 17,511
                                          ========   ========   ========   ========   ========

Net income                                $  8,497   $  4,351   $  3,621   $  8,244   $ 11,127
                                          ========   ========   ========   ========   ========

Net income allocated to:
    Managing Partner                      $  2,102   $  1,269   $  1,061   $  1,967   $  2,652
    Investing Partners                       6,395      3,082      2,560      6,277      8,475
                                          --------   --------   --------   --------   --------

                                          $  8,497   $  4,351   $  3,621   $  8,244   $ 11,127
                                          ========   ========   ========   ========   ========

Net income per Investing
    Partner Unit                          $  5,654   $  2,707   $  2,193   $  5,260   $  7,032
                                          ========   ========   ========   ========   ========

Cash distributions per
    Investing Partner Unit                $  5,750   $  3,500   $  1,500   $  4,500   $  4,500
                                          ========   ========   ========   ========   ========
</TABLE>



                                       5
<PAGE>   8

ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
        OF OPERATIONS

     The Partnership's net income and net income per Investing Partner Unit
increased in 2000 due to higher oil and gas prices and reduced operating costs.
The average gas price realized by the Partnership in 2000 increased 77 percent
from the average price in 1999, while the Partnership's average crude oil price
increased 67 percent from last year. Distributions per Investing Partner Unit in
2000 increased with improved product prices.


RESULTS OF OPERATIONS

NET INCOME AND REVENUE

     The Partnership reported net income of $8.5 million for 2000 versus $4.4
million in 1999. Net income per Investing Partner Unit more than doubled,
increasing from $2,707 in 1999 to $5,654 in 2000. Significantly higher oil and
gas prices in 2000 more than offset lower oil and gas production during the
year.

     Revenues increased 46 percent, from $8.6 million in 1999, to $12.5 million
in 2000. Natural gas sales accounted for 71 percent of the Partnership's total
revenue in 2000, compared to 73 percent during 1999. The Partnership is not in a
position to predict future oil and gas prices.

     The Partnership's oil and gas production volume and price information is
summarized in the following table:

<TABLE>
<CAPTION>
                                                              FOR THE YEAR ENDED
                                                                 DECEMBER 31,
                                                      -----------------------------------       INCREASE
                                                           2000               1999             (DECREASE)
                                                      ----------------   ----------------    ----------------
<S>                                                   <C>                <C>                 <C>
          Gas volumes - Mcf per day                        6,337              8,049                (21)%
          Average gas price - per Mcf                    $  3.81            $  2.15                 77%
          Oil volume - barrels per day                       324                335                 (3)%
          Average oil price - per barrel                 $ 30.16            $ 18.10                 67%
</TABLE>

     Declines in oil and gas production can be expected in future years due to
normal depletion. It is not anticipated that the Partnership will acquire any
additional exploratory leases or that significant exploratory drilling will take
place on leases in which the Partnership currently holds interests.

2000 COMPARED TO 1999

OIL AND GAS SALES

     Natural gas sales for 2000 totaled $8.8 million, up 40 percent over 1999,
as higher gas prices more than offset the impact of lower gas production. The
Partnership's average realized gas price increased $1.66 per Mcf from 1999,
positively impacting sales by $4.9 million. Gas production in 2000 decreased by
21 percent when compared to 1999, negatively impacting sales by $2.4 million.
Production decreases in 2000 were primarily due to natural production declines
at Matagorda 681, and the Partnership taking less than its entitled share of
production at Ship Shoal 259 and North Padre Island 969 to make-up gas
imbalances with another working-interest owner. These decreases were partially
offset by production added from a sidetrack well completed at East Cameron 60 in
late 1999 and drilling projects at South Timbalier 295 during 2000.

     The Partnership's crude oil sales for 2000 totaled $3.6 million, a 62
percent increase from 1999. The average realized price for 2000 increased $12.06
per barrel, or 67 percent, when compared to 1999. Oil production in 2000 slipped
three percent from a year ago due to natural depletion.

     Given the small number of producing wells owned by the Partnership, and the
fact that offshore wells tend to decline at a faster rate than onshore wells,
the Partnership's future production will be subject to more volatility than
those companies with greater reserves and longer-lived properties. At December
31, 2000, South Timbalier Block 295 accounted for approximately 63 percent of
the Partnership's projected remaining equivalent proved reserves and 45 percent
of discounted future net cash flows relating to proved reserves.



                                       6
<PAGE>   9

OPERATING EXPENSES

     The Partnership's depreciation, depletion and amortization (DD&A) rate,
expressed as a percentage of oil and gas sales, was approximately 24 percent
during 2000, down from 1999. The decrease in the DD&A rate was a result of
reserve additions and favorable reserve revisions recognized in 2000. Overall,
2000 DD&A expense of $3 million decreased approximately $.1 million when
compared to 1999.

     Lease operating expense (LOE) of $.5 million declined by approximately $.1
million during 2000 when compared to 1999 due to lower repair and maintenance
costs and the receipt of an audit exception refund from an outside operator in
2000.

1999 COMPARED TO 1998

OIL AND GAS SALES

     Natural gas sales for 1999 totaled $6.3 million, down slightly from 1998,
as lower gas production more than offset the impact of higher realized gas
prices. The decrease in production volumes resulted primarily from normal
declines at Matagorda Island Block 681 and the sale of the partnership interest
in Matagorda Island 705 during 1999.

     The Partnership's crude oil sales for 1999 totaled $2.2 million, a 68
percent increase from 1998. The average realized price for 1999 increased 46
percent when compared to 1998. In addition to the increase in crude oil prices,
the Partnership recognized a 15 percent increase in production versus 1998. The
increase in oil production resulted primarily from a new completion at East
Cameron Block 60 and recompletion operations at South Timbalier Block 295.

OPERATING EXPENSES

     The Partnership's DD&A rate, expressed as a percentage of oil and gas
sales, was approximately 36 percent during 1999, up slightly for 1998. The
increase in the DD&A rate was a result of decreased natural gas and crude oil
prices and unfavorable reserve revisions recognized in late 1998. Overall, 1999
DD&A expense of $3 million increased by $.3 million when compared to 1998.

     LOE of $.7 million decreased by $.3 million during 1999 when compared to
1998. The decrease in LOE was the result of lower workover activity in 1999.


CASH FLOW, LIQUIDITY AND CAPITAL RESOURCES

CAPITAL COMMITMENTS

     The Partnership's primary needs for cash are for operating expenses,
drilling and recompletion expenditures, future dismantlement and abandonment
costs, distributions to Investing Partners, and the purchase of Units offered by
Investing Partners under the right of presentment. The Partnership had no
outstanding debt at December 31, 2000.

     During 2000, the Partnership's oil and gas property additions totaled $3.9
million. These additions primarily related to drilling and recompletion projects
at South Timbalier Block 295 and a compressor upgrade at Matagorda Block
681/682. During 2000, the Partnership completed one development well and three
sidetrack wells at South Timbalier Block 295 as producing wells. The Partnership
also participated in one dry hole at Matagorda Island Block 682/681 during 2000.
At Matagorda Island Block 681/682, a compressor on the platform was modified to
increase the recoverable reserves from the field. Additions to oil and gas
properties totaled $1.4 million and $2.3 million in 1999 and 1998, respectively.

     The Partnership anticipates capital expenditures will total approximately
$2.4 million in 2001, based on preliminary information provided by the operators
of the properties in which the Partnership owns interests. The anticipated
capital expenditures relate primarily to drilling and recompletion activity at
South Timbalier Block 295. Additional capital expenditures may be proposed by
the operators in the future. Estimates of future capital expenditures may also
change based on realized oil and gas prices, drilling results and the cost
charged by service providers.



                                       7
<PAGE>   10

     During 2000, the Partnership paid distributions to Investing Partners
totaling approximately $6.5 million or $5,750 per Unit, which was 64 percent
higher than the per Unit distribution in 1999. Apache, as the Managing Partner,
will review the possibility of distributions in 2001 given current revenues and
available cash balances. Future distributions will be dependent on actual and
expected production levels, realized and expected oil and gas prices,
anticipated capital expenditures, and prudent cash reserves for future
dismantlement and abandonment costs that will be incurred after the
Partnership's reserves are depleted.

     In February 1994, an amendment to the Partnership Agreement created a right
of presentment under which all Investing Partners have a limited and voluntary
right to offer their Units to the Partnership twice each year to be purchased
for cash. In 2000, the first right of presentment offer of $8,874 per Unit, plus
interest to the date of payment, was made to Investing Partners based on a
December 31, 1999 valuation date. The second right of presentment offer of
$6,431 per Unit, plus interest to the date of payment, was made to the Investing
Partners based on a valuation date of June 30, 2000. As a result, the
Partnership acquired 4.00 Units for a total of $34,831 in cash. In 1999 and
1998, Investing Partners were paid $69,386 and $487,313, respectively, for a
total of 51.71 Units.

     There will be two rights of presentment in 2001, but the Partnership is not
in a position to predict how many Units will be presented for repurchase and
cannot, at this time, determine if the Partnership will have sufficient funds
available to repurchase Units. The Amended Partnership Agreement contains
limitations on the number of Units that the Partnership can repurchase,
including an annual limit on repurchases of 10 percent of outstanding Units. The
Partnership has no obligation to repurchase any Units presented to the extent
that it determines that it has insufficient funds for such repurchases.

CAPITAL RESOURCES AND LIQUIDITY

     The Partnership's primary capital resource is net cash provided by
operating activities, which totaled $11.2 million for 2000. Net cash provided by
operating activities increased $2.9 million, or 35 percent, in 2000 due to
improved oil and gas prices and lower LOE. Future operating cash flows will be
influenced by oil and gas prices and production which cannot be predicted.

     The Partnership's future financial condition and results of operations will
largely depend upon prices received for its oil and natural gas production and
the costs of acquiring, finding, developing and producing reserves. A
substantial portion of the Partnership's production is sold under
market-sensitive contracts. Prices for oil and natural gas are subject to
fluctuations in response to changes in supply, market uncertainty and a variety
of factors beyond the Partnership's control. These factors include worldwide
political instability (especially in the Middle East), the foreign supply of oil
and natural gas, the price of foreign imports, the level of consumer demand and
the price and availability of alternative fuels. With natural gas accounting for
77 percent of the Partnership's 2000 production and 60 percent of total proved
reserves, on an energy equivalent basis, the Partnership is affected more by
fluctuations in natural gas prices than in oil prices.

     It is expected that the net cash provided by operating activities will be
sufficient to meet the Partnership's liquidity needs for routine operations over
the next two years. However, in the event that future short-term operating cash
requirements are greater than the Partnership's financial resources, the
Partnership may seek short-term, interest-bearing advances from the Managing
Partner as needed.

FORWARD-LOOKING STATEMENTS AND RISK

     Certain statements in this report, including statements of the future
plans, objectives, and expected performance of the Partnership, are
forward-looking statements that are dependent upon certain events, risks and
uncertainties that may be outside the Partnership's control, and which could
cause actual results to differ materially from those anticipated. Some of these
include, but are not limited to, the market prices of oil and gas, economic and
competitive conditions, inflation rates, legislative and regulatory changes,
financial market conditions, political and economic uncertainties of foreign
governments, future business decisions, and other uncertainties, all of which
are difficult to predict.

     There are numerous uncertainties inherent in estimating quantities of
proved oil and gas reserves and in projecting future rates of production and the
timing of development expenditures. The total amount or timing of actual future
production may vary significantly from reserves and production estimates. The
drilling of exploratory wells can involve significant risks, including those
related to timing, success rates and cost overruns. Lease and rig availability,
complex geology and other factors can affect these risks. Fluctuations in oil
and gas prices, or a prolonged period of low prices, may substantially adversely
affect the Partnership's financial position, results of operations and cash
flows.



                                       8
<PAGE>   11

ITEM 7A. MARKET RISK

COMMODITY RISK

     The Partnership's major market risk exposure is in the pricing applicable
to its oil and gas production. Realized pricing is primarily driven by the
prevailing worldwide price for crude oil and spot prices applicable to its
natural gas production. Historically, prices received for oil and gas production
have been volatile and unpredictable and price volatility is expected to
continue. During 2000, monthly oil price realizations ranged from a low of
$23.93 per barrel to a high of $34.27 per barrel. Gas price realizations ranged
from a monthly low of $2.24 per Mcf to a monthly high of $6.28 per Mcf during
the same period. The Partnership did not use derivative financial instruments or
otherwise engage in hedging activities during the three-year period ended
December 31, 2000.



                                       9
<PAGE>   12

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

                     APACHE OFFSHORE INVESTMENT PARTNERSHIP

                          INDEX TO FINANCIAL STATEMENTS


<TABLE>
<CAPTION>
                                                                                                              PAGE
                                                                                                             NUMBER
                                                                                                             ------
<S>                                                                                                          <C>
Report of Independent Public Accountants..........................................................              11

Statement of Income for each of the three years in the period ended December 31, 2000.............              12

Statement of Cash Flows for each of the three years in the period ended December 31, 2000 ........              13

Balance Sheet as of December 31, 2000 and 1999....................................................              14

Statement of Changes in Partners' Capital for each of the three years in the period ended
    December 31, 2000.............................................................................              15

Notes to Financial Statements.....................................................................              16

Supplemental Oil and Gas Disclosures..............................................................              22
</TABLE>


Schedules -

     All financial statement schedules have been omitted because they are either
not required, not applicable or the information required to be presented is
included in the financial statements or related notes thereto.



                                       10
<PAGE>   13

                    REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS




To the Partners of Apache Offshore Investment Partnership:

     We have audited the accompanying balance sheet of Apache Offshore
Investment Partnership (a Delaware partnership) as of December 31, 2000 and
1999, and the related statements of income, cash flows and changes in partners'
capital for each of the three years in the period ended December 31, 2000. These
financial statements are the responsibility of the Partnership's management. Our
responsibility is to express an opinion on these financial statements based on
our audits.

     We conducted our audits in accordance with auditing standards generally
accepted in the United States. Those standards require that we plan and perform
the audit to obtain reasonable assurance about whether the financial statements
are free of material misstatement. An audit includes examining, on a test basis,
evidence supporting the amounts and disclosures in the financial statements. An
audit also includes assessing the accounting principles used and significant
estimates made by management, as well as evaluating the overall financial
statement presentation. We believe that our audits provide a reasonable basis
for our opinion.

     In our opinion, the financial statements referred to above present fairly,
in all material respects, the financial position of Apache Offshore Investment
Partnership as of December 31, 2000 and 1999, and the results of its operations
and its cash flows for each of the three years in the period ended December 31,
2000, in conformity with accounting principles generally accepted in the United
States.




                                                 ARTHUR ANDERSEN LLP


Houston, Texas
March 1, 2001



                                       11
<PAGE>   14

                     APACHE OFFSHORE INVESTMENT PARTNERSHIP
                               STATEMENT OF INCOME


<TABLE>
<CAPTION>
                                                     FOR THE YEAR ENDED DECEMBER 31,
                                               ------------------------------------------
                                                   2000           1999           1998
                                               ------------   ------------   ------------
<S>                                            <C>            <C>            <C>
REVENUES:
    Oil and gas sales                          $ 12,416,857   $  8,521,418   $  7,827,380
    Interest income                                 123,820         92,084         55,691
                                               ------------   ------------   ------------

                                                 12,540,677      8,613,502      7,883,071
                                               ------------   ------------   ------------

OPERATING EXPENSES:
    Depreciation, depletion and amortization      2,971,525      3,044,474      2,721,180
    Lease operating                                 532,433        673,216      1,000,708
    Administrative                                  540,000        544,760        540,000
                                               ------------   ------------   ------------

                                                  4,043,958      4,262,450      4,261,888
                                               ------------   ------------   ------------

NET INCOME                                     $  8,496,719   $  4,351,052   $  3,621,183
                                               ============   ============   ============

NET INCOME ALLOCATED TO:
    Managing Partner                           $  2,102,310   $  1,268,895   $  1,061,052
    Investing Partners                            6,394,409      3,082,157      2,560,131
                                               ------------   ------------   ------------

                                               $  8,496,719   $  4,351,052   $  3,621,183
                                               ============   ============   ============

NET INCOME PER INVESTING PARTNER UNIT          $      5,654   $      2,707   $      2,193
                                               ============   ============   ============

WEIGHTED AVERAGE INVESTING PARTNER
    UNITS OUTSTANDING                               1,130.9        1,138.4        1,167.4
                                               ============   ============   ============
</TABLE>



               The accompanying notes to financial statements are
                       an integral part of this statement.



                                       12
<PAGE>   15

                     APACHE OFFSHORE INVESTMENT PARTNERSHIP
                             STATEMENT OF CASH FLOWS


<TABLE>
<CAPTION>
                                                                    FOR THE YEAR ENDED DECEMBER 31,
                                                            --------------------------------------------
                                                                2000            1999            1998
                                                            ------------    ------------    ------------
<S>                                                         <C>             <C>             <C>
CASH FLOWS FROM OPERATING ACTIVITIES:
   Net income                                               $  8,496,719    $  4,351,052    $  3,621,183
   Adjustments to reconcile net income to net cash
     provided by operating activities:
     Depreciation, depletion and amortization                  2,971,525       3,044,474       2,721,180
     Changes in operating assets and liabilities:
       (Increase) decrease in accrued revenues receivable       (388,472)        662,173         239,452
       Increase (decrease) in accrued operating
         expenses                                                (87,287)         73,704         (13,896)
       Increase (decrease) in payable to/receivable from
         Apache Corporation                                      192,624         128,658         288,702
                                                            ------------    ------------    ------------

     Net cash provided by operating activities                11,185,109       8,260,061       6,856,621
                                                            ------------    ------------    ------------

CASH FLOWS FROM INVESTING ACTIVITIES:
   Additions to oil and gas properties                        (3,882,050)     (1,376,072)     (2,331,287)
   Proceeds from sales of oil and gas properties                      --         211,426         396,674
   Non-cash portion of oil and gas property additions            (85,851)          4,931      (1,172,997)
   Decrease in drilling advances                                      --              --          72,020
                                                            ------------    ------------    ------------

     Net cash used in investing activities                    (3,967,901)     (1,159,715)     (3,035,590)
                                                            ------------    ------------    ------------

CASH FLOWS FROM FINANCING ACTIVITIES:
   Repurchase of Partnership Units                               (34,831)        (69,386)       (487,313)
   Distributions to Investing Partners                        (6,500,003)     (3,979,221)     (1,731,539)
   Distributions to Managing Partner, net                     (1,988,308)     (1,627,876)       (969,027)
                                                            ------------    ------------    ------------

     Net cash used in financing activities                    (8,523,142)     (5,676,483)     (3,187,879)
                                                            ------------    ------------    ------------

NET INCREASE (DECREASE) IN CASH AND CASH
   EQUIVALENTS                                                (1,305,934)      1,423,863         633,152

CASH AND CASH EQUIVALENTS, BEGINNING
   OF YEAR                                                     2,748,812       1,324,949         691,797
                                                            ------------    ------------    ------------

CASH AND CASH EQUIVALENTS, END OF YEAR                      $  1,442,878    $  2,748,812    $  1,324,949
                                                            ============    ============    ============
</TABLE>



               The accompanying notes to financial statements are
                       an integral part of this statement.



                                       13
<PAGE>   16

                     APACHE OFFSHORE INVESTMENT PARTNERSHIP
                                  BALANCE SHEET


<TABLE>
<CAPTION>
                                                                            DECEMBER 31,
                                                                  --------------------------------
                                                                       2000              1999
                                                                  --------------    --------------
<S>                                                               <C>               <C>
                                     ASSETS

CURRENT ASSETS:
    Cash and cash equivalents                                     $    1,442,878    $    2,748,812
    Accrued revenues receivable                                        1,024,298           635,826
                                                                  --------------    --------------

                                                                       2,467,176         3,384,638
                                                                  --------------    --------------

OIL AND GAS PROPERTIES, on the basis of full cost accounting:
    Proved properties                                                173,378,396       169,496,346
    Less - Accumulated depreciation, depletion and amortization     (167,130,093)     (164,158,568)
                                                                  --------------    --------------

                                                                       6,248,303         5,337,778
                                                                  --------------    --------------

                                                                  $    8,715,479    $    8,722,416
                                                                  ==============    ==============


                        LIABILITIES AND PARTNERS' CAPITAL

CURRENT LIABILITIES:
    Accrued exploration and development                           $      511,000    $      596,851
    Accrued operating expenses                                            84,784           172,071
    Payable to Apache Corporation                                        391,255           198,631
                                                                  --------------    --------------

                                                                         987,039           967,553
                                                                  --------------    --------------

PARTNERS' CAPITAL:
    Managing Partner                                                     352,081           238,079
    Investing Partners (1,128.5 and 1,132.5 Units
       outstanding, respectively)                                      7,376,359         7,516,784
                                                                  --------------    --------------

                                                                       7,728,440         7,754,863
                                                                  --------------    --------------

                                                                  $    8,715,479    $    8,722,416
                                                                  ==============    ==============
</TABLE>



               The accompanying notes to financial statements are
                       an integral part of this statement.



                                       14
<PAGE>   17

                     APACHE OFFSHORE INVESTMENT PARTNERSHIP
                    STATEMENT OF CHANGES IN PARTNERS' CAPITAL


<TABLE>
<CAPTION>
                                      MANAGING       INVESTING
                                      PARTNER         PARTNERS         TOTAL
                                    ------------    ------------    ------------
<S>                                 <C>             <C>             <C>
BALANCE, DECEMBER 31, 1997          $    505,035    $  8,141,955    $  8,646,990

  Distributions, net                    (969,027)     (1,731,539)     (2,700,566)

  Repurchase of Partnership Units             --        (487,313)       (487,313)

  Net income                           1,061,052       2,560,131       3,621,183
                                    ------------    ------------    ------------

BALANCE, DECEMBER 31, 1998               597,060       8,483,234       9,080,294

  Distributions, net                  (1,627,876)     (3,979,221)     (5,607,097)

  Repurchase of Partnership Units             --         (69,386)        (69,386)

  Net income                           1,268,895       3,082,157       4,351,052
                                    ------------    ------------    ------------

BALANCE, DECEMBER 31, 1999               238,079       7,516,784       7,754,863

  Distributions, net                  (1,988,308)     (6,500,003)     (8,488,311)

  Repurchase of Partnership Units             --         (34,831)        (34,831)

  Net income                           2,102,310       6,394,409       8,496,719
                                    ------------    ------------    ------------

BALANCE, DECEMBER 31, 2000          $    352,081    $  7,376,359    $  7,728,440
                                    ============    ============    ============
</TABLE>



               The accompanying notes to financial statements are
                       an integral part of this statement.



                                       15
<PAGE>   18

                     APACHE OFFSHORE INVESTMENT PARTNERSHIP
                          NOTES TO FINANCIAL STATEMENTS


(1)  ORGANIZATION

     NATURE OF OPERATIONS -

         Apache Offshore Investment Partnership was formed as a Delaware general
     partnership on October 31, 1983, consisting of Apache Corporation (Apache)
     as Managing Partner and public investors as Investing Partners. The general
     partnership invested its entire capital in Apache Offshore Petroleum
     Limited Partnership, a Delaware limited partnership formed to conduct oil
     and gas exploration, development and production operations. The
     accompanying financial statements include the accounts of both the limited
     and general partnerships. Apache is the general partner of both the limited
     and general partnerships, and holds approximately five percent of the
     1,128.5 Investing Partner Units (Units) outstanding at December 31, 2000.
     The term "Partnership", as used hereafter, refers to the limited or the
     general partnership, as the case may be.

         The Partnership purchased, at cost, an 85 percent interest in offshore
     leasehold interests acquired by Apache as a co-venturer in a series of oil
     and gas exploration, development and production activities on 87 federal
     lease tracts (12 remain as of December 31, 2000) in the Gulf of Mexico,
     offshore Louisiana and Texas. The remaining 15 percent interest was
     purchased by an affiliated partnership or retained by Apache. The
     Partnership acquired an increased net revenue interest in Matagorda Island
     Blocks 681 and 682 in November 1992, when the Partnership and Apache formed
     a joint venture to acquire a 92.6 percent working interest in the blocks.

         Since inception, the Partnership has participated in 14 federal
     offshore lease sales in which 49 prospects were acquired (through the same
     date 42 of those prospects have been surrendered/sold). The Partnership's
     working interests in the seven remaining venture prospects range from 6.29
     percent to 9.44 percent.

         The Partnership's future financial condition and results of operations
     will depend largely upon prices received for its oil and natural gas
     production and the costs of acquiring, finding, developing and producing
     reserves. A substantial portion of the Partnership's production is sold
     under market-sensitive contracts. Prices for oil and natural gas are
     subject to fluctuations in response to changes in supply, market
     uncertainty and a variety of factors beyond the Partnership's control.
     These factors include worldwide political instability (especially in the
     Middle East), the foreign supply of oil and natural gas, the price of
     foreign imports, the level of consumer demand, and the price and
     availability of alternative fuels. With natural gas accounting for 77
     percent of the Partnership's 2000 production and 60 percent of total proved
     reserves, on an energy equivalent basis, the Partnership is affected more
     by fluctuations in natural gas prices than in oil prices.

         Under the terms of the Partnership Agreements, the Investing Partners
     receive 80 percent and Apache receives 20 percent of revenue. Lease
     operating and administrative expenses are allocated to the Investing
     Partners and Apache in the same proportion as revenues. The Investing
     Partners generally pay for 90 percent and Apache generally pays for 10
     percent of exploration and development costs and expenses incurred by the
     Partnership. However, intangible drilling costs, interest costs and fees or
     expenses related to the loans incurred by the Partnership are allocated 99
     percent to the Investing Partners and one percent to Apache until such time
     as the amount so allocated to the Investing Partners equals 90 percent of
     the total amount of such costs, including such costs incurred by Apache
     prior to the formation of the Partnerships.



                                       16
<PAGE>   19

                     APACHE OFFSHORE INVESTMENT PARTNERSHIP
                   NOTES TO FINANCIAL STATEMENTS - (CONTINUED)

     RIGHT OF PRESENTMENT -

         An amendment to the Partnership Agreement adopted in February 1994,
     created a right of presentment under which all Investing Partners have a
     limited and voluntary right to offer their Units to the Partnership twice
     each year to be purchased for cash. During 2000, the Investing Partners
     sold a total of 4.0 Units to the Partnership for a total of $34,831 in
     cash. The first right of presentment was based upon a valuation date of
     December 31, 1999 for a purchase price of $8,874 per Unit, plus interest to
     the date of payment. The second presentment offer was based on a valuation
     date of June 30, 2000 for a purchase price of $6,431 per Unit, plus
     interest to the payment date. During 1999 and 1998, the Partnership paid
     the Investing Partners $69,386 and $487,313, respectively, to acquire a
     total of 51.71 Units.

         The Partnership is not in a position to predict how many Units will be
     presented for repurchase during 2001, however, no more than 10 percent of
     the outstanding Units may be purchased under the right of presentment in
     any year. The Partnership has no obligation to purchase any Units presented
     to the extent that it determines that it has insufficient funds for such
     purchases.

         The table below sets forth the total repurchase price and the
     repurchase price per Unit for all outstanding Units at each presentment
     period, based on the right of presentment valuation formula defined in the
     amendment to the Partnership Agreement. The right of presentment offers,
     made twice annually, are based on a discounted Unit value formula. The
     discounted Unit value will be not less than the Investing Partner's share
     of: (a) the sum of (i) 70 percent of the discounted estimated future net
     revenues from proved reserves, discounted at a rate of 1.5 percent over
     prime or First National Bank of Chicago's base rate in effect at the time
     the calculation is made, (ii) cash on hand, (iii) prepaid expenses, (iv)
     accounts receivable less a reasonable reserve for doubtful accounts, (v)
     oil and gas properties other than proved reserves at cost less any amounts
     attributable to drilling and completion costs incurred by the Partnership
     and included therein, and (vi) the book value of all other assets of the
     Partnership, less the debts, obligations and other liabilities of all kinds
     (including accrued expenses) then allocable to such interest in the
     Partnership, all determined as of the valuation date, divided by (b) the
     number of Units, and fractions thereof, outstanding as of the valuation
     date. The discounted Unit value does not purport to be, and may be
     substantially different from, the fair market value of a Unit.

<TABLE>
<CAPTION>
                   RIGHT OF PRESENTMENT                  TOTAL REPURCHASE                REPURCHASE PRICE
                      VALUATION DATE                          PRICE                          PER UNIT
                 -------------------------               ----------------                ----------------
<S>                                                      <C>                             <C>
                 December 31, 1997                       $     13,216,700                $        11,161
                 June 30, 1998                                 13,072,171                          9,824
                 December 31, 1998                             10,451,244                          8,410
                 June 30, 1999                                 10,812,281                          6,769
                 December 31, 1999                             12,314,303                          8,874
                 June 30, 2000                                 10,934,084                          6,431
</TABLE>

     CAPITAL CONTRIBUTIONS -

         A total of $85,000 per Unit, or approximately 57 percent, of investor
     subscription had been called through December 31, 2000. The Partnership
     determined the full purchase price of $150,000 per Unit was not needed, and
     upon completion of the last subscription call in November 1989, released
     the Investing Partners from their remaining liability. As a result of
     investors defaulting on cash calls and repurchases under the presentment
     offer discussed above, the original 1,500 Units have been reduced to
     1,128.5 Units at December 31, 2000.



                                       17
<PAGE>   20

                     APACHE OFFSHORE INVESTMENT PARTNERSHIP
                   NOTES TO FINANCIAL STATEMENTS - (CONTINUED)


(2)  SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

     STATEMENT PRESENTATION -

         The accounts of the Partnership are maintained on a tax basis method of
     accounting in accordance with the Articles of Partnership and methods of
     reporting allowed for federal income tax purposes.

         Financial statements included in reports that the Partnership files
     with the Securities and Exchange Commission (SEC) are required to be
     prepared in conformity with generally accepted accounting principles.
     Accordingly, the accompanying financial statements include adjustments to
     convert from tax basis to the accrual basis method in conformity with
     accounting principles generally accepted in the United States.

     CASH EQUIVALENTS -

         The Partnership considers all highly liquid debt instruments purchased
     with an original maturity of three months or less to be cash equivalents.
     These investments are carried at cost which approximates market.

     OIL AND GAS PROPERTIES -

         The Partnership uses the full cost method of accounting for financial
     statement purposes. Under this method, the Partnership capitalizes all
     acquisition, exploration and development costs incurred for the purpose of
     finding oil and gas reserves. The amounts capitalized under this method
     include dry hole costs, leasehold costs, engineering, geological,
     exploration, development and other similar costs. Costs associated with
     production and administrative functions are expensed in the period
     incurred. Unless a significant portion of the Partnership's reserve volumes
     are sold (greater than 25 percent), proceeds from the sale of oil and gas
     properties are accounted for as reductions to capitalized costs, and gains
     or losses are not recognized.

         Capitalized costs of oil and gas properties are amortized on the future
     gross revenue method whereby depreciation, depletion and amortization
     (DD&A) expense is computed quarterly by dividing current period oil and gas
     sales by estimated future gross revenue from proved oil and gas reserves
     (including current period oil and gas sales) and applying the resulting
     rate to the net cost of evaluated oil and gas properties, including
     estimated future development costs. The amortizable base includes estimated
     dismantlement, restoration and abandonment costs, net of estimated salvage
     values.

         The Partnership limits the capitalized costs of proved oil and gas
     properties, net of accumulated DD&A, to the estimated future net cash flows
     from proved oil and gas reserves discounted at 10 percent, plus the lower
     of cost or fair value of unproved properties included in the costs being
     amortized, if any. If capitalized costs exceed this limit, the excess is
     charged to DD&A expense. The Partnership has not recorded any write-downs
     of capitalized costs for the three years presented.

     REVENUE RECOGNITION -

         The Partnership uses the sales method of accounting for natural gas
     revenues. Under this method, revenues are recognized based on actual
     volumes of gas sold to purchasers. The volumes of gas sold may differ from
     the volumes to which the Partnership is entitled based on its interests in
     the properties. Revenue is deferred and a liability is recorded for those
     properties where the estimated remaining reserves will not be sufficient to
     enable the underproduced owner to recoup its entitled share through
     production.

     NET INCOME PER INVESTING UNIT -

         The net income per Investing Partner Unit is calculated by dividing the
     aggregate Investing Partners' net income for the period by the number of
     weighted average Investing Partner Units outstanding for that period.



                                       18
<PAGE>   21

                     APACHE OFFSHORE INVESTMENT PARTNERSHIP
                   NOTES TO FINANCIAL STATEMENTS - (CONTINUED)

     INCOME TAXES -

         The profit or loss of the Partnership for federal income tax reporting
     purposes is included in the income tax returns of the partners.
     Accordingly, no recognition has been given to income taxes in the
     accompanying financial statements.

     USE OF ESTIMATES -

         The preparation of financial statements in conformity with generally
     accepted accounting principles requires management to make estimates and
     assumptions that affect the reported amounts of assets and liabilities and
     disclosure of contingent assets and liabilities at the date of the
     financial statements and the reported amounts of revenues and expenses
     during the reporting period. Actual results could differ from those
     estimates. Significant estimates with regard to these financial statements
     include the estimate of proved oil and gas reserve quantities and the
     related present value of estimated future net cash flows therefrom. See
     "Supplemental Oil and Gas Disclosures" below.

     PAYABLE TO/RECEIVABLE FROM APACHE -

         Payable to/receivable from Apache represents the net result of the
     Investing Partners' revenue and expenditure transactions in the current
     month. Generally, this amount will be transferred to or funded by Apache,
     as appropriate, in the month after the Partnership's transactions are
     processed and the net results from operations are determined.

     MAINTENANCE AND REPAIRS -

         Maintenance and repairs are charged to expense as incurred.
     Recompletions and replacements that improve or extend the life of existing
     properties are capitalized.


(3)  COMPENSATION TO APACHE

         Apache is entitled to the following types of compensation and
     reimbursement for costs and expenses.

<TABLE>
<CAPTION>
                                                                          TOTAL REIMBURSED BY THE INVESTING
                                                                       PARTNERS FOR THE YEAR ENDED DECEMBER 31,
                                                                      ------------------------------------------
                                                                          2000           1999           1998
                                                                      ------------   ------------   ------------
                                                                                    (In thousands)
<S>                                                                   <C>            <C>            <C>
        a. Apache is reimbursed for general, administrative and
           overhead expenses incurred in connection with the
           management and operation of the Partnership's business     $        432   $        436   $        432
                                                                      ============   ============   ============

        b. Apache is reimbursed for exploration and development
           overhead costs incurred in the Partnership's operations
           These costs are based on exploration and development
           activities and are capitalized to oil and gas properties   $        190   $         73   $        140
                                                                      ============   ============   ============
</TABLE>

         Apache operates certain Partnership properties. Billings to the
     Partnership are made on the same basis as to unaffiliated third parties or
     at prevailing industry rates.



                                       19
<PAGE>   22

                     APACHE OFFSHORE INVESTMENT PARTNERSHIP
                   NOTES TO FINANCIAL STATEMENTS - (CONTINUED)

(4)  OIL AND GAS PROPERTIES

         The following tables contain direct cost information and changes in the
     Partnership's oil and gas properties for each of the years ended December
     31. All costs of oil and gas properties are currently being amortized.

<TABLE>
<CAPTION>
                                             2000         1999          1998
                                          ----------   ----------    ----------
                                                     (In thousands)
<S>                                       <C>          <C>           <C>
        Oil and Gas Properties

        Balance, beginning of year        $  169,496   $  168,332    $  166,397
        Costs incurred during the year:
          Leasehold additions -
             Investing Partners                   --           --            17
             Managing Partner                     --           --             2
          Development -
             Investing Partners                3,696        1,367         2,257
             Managing Partner                    186            9            56
          Property sales proceeds(1) -
             Investing Partners                   --         (191)         (357)
             Managing Partner                     --          (21)          (40)
                                          ----------   ----------    ----------

        Balance, end of year              $  173,378   $  169,496    $  168,332
                                          ==========   ==========    ==========
</TABLE>

(1)  The 1999 property sale proceeds reflect the sale of the Partnership's
     interest in Matagorda Island Block 705 (Roberto Prospect) and the
     southwest quadrant of North Padre Island Block 976 (Rosita Prospect). The
     1998 property sales proceeds are a result of the sale of West Cameron Block
     368 (Krypton Prospect).

<TABLE>
<CAPTION>
                                                                MANAGING    INVESTING
                                                                 PARTNER     PARTNERS       TOTAL
                                                               ----------   ----------   ----------
                                                                          (In thousands)
<S>                                                            <C>          <C>          <C>
        Accumulated Depreciation, Depletion and Amortization

        Balance, December 31, 1997                             $   19,905   $  138,488   $  158,393
          Provision                                                   196        2,525        2,721
                                                               ----------   ----------   ----------

        Balance, December 31, 1998                                 20,101      141,013      161,114
          Provision                                                   197        2,847        3,044
                                                               ----------   ----------   ----------

        Balance, December 31, 1999                                 20,298      143,860      164,158
          Provision                                                   167        2,805        2,972
                                                               ----------   ----------   ----------

        Balance, December 31, 2000                             $   20,465   $  146,665   $  167,130
                                                               ==========   ==========   ==========
</TABLE>

         The Partnership's aggregate DD&A expense as a percent of oil and gas
     sales for 2000, 1999 and 1998 was 24 percent, 36 percent and 35 percent,
     respectively.



                                       20
<PAGE>   23

                     APACHE OFFSHORE INVESTMENT PARTNERSHIP
                   NOTES TO FINANCIAL STATEMENTS - (CONTINUED)

(5)  MAJOR CUSTOMER INFORMATION

         Revenues received from major third party customers that exceeded 10
     percent of oil and gas sales are discussed below. No other third party
     customers individually accounted for more than ten percent of oil and gas
     sales.

         Sales to Cinergy Marketing & Trading, LLC accounted for 71 percent, 74
     percent, and 82 percent of the Partnership's oil and gas sales in 2000,
     1999 and 1998, respectively. In June 1998, Apache formed a strategic
     alliance with Cinergy Corp. (Cinergy) to market substantially all of
     Apache's natural gas production from North America and sold its 57 percent
     interest in Producers Energy Marketing LLC (ProEnergy) to Cinergy.
     ProEnergy, renamed Cinergy Marketing & Trading, LLC, will continue to
     market Apache's North American natural gas production for 10 years, with an
     option to terminate after six years, under an amended and restated gas
     purchase agreement effective July 1, 1998. The prices the Partnership
     received for its gas production prior to the sale of ProEnergy were, in the
     opinion of Apache, comparable to the prices that would have been received
     from a non-affiliated party. The prices the Partnership received after the
     sale of ProEnergy and will continue to receive for its gas production, in
     the opinion of Apache, approximate market prices.

         During 2000, Apache Crude Oil Marketing, Inc., a wholly-owned
     subsidiary of Apache purchased oil and condensate from the Partnership
     which accounted for approximately 12 percent of the Partnership's total oil
     and gas sales. The prices the Partnership received for these sales were
     based on third-party pricing indexes, and in the opinion of Apache,
     comparable to prices that would have been received from a non-affiliated
     party.

         Sales of oil and condensate to Williams Energy Marketing & Trading
     Company accounted for 10 percent of the Partnership's oil and gas sales in
     2000, while sales to Plains Petroleum Operating Co. accounted for 26
     percent and 17 percent of the Partnership's oil and gas sales in 1999 and
     1998, respectively.

         Effective November 1992, with Apache's and the Partnership's
     acquisition of an additional net revenue interest in Matagorda Island
     Blocks 681 and 682, a wholly-owned subsidiary of Apache purchased from
     Shell Oil Company (Shell) a 14.4 mile natural gas and condensate pipeline
     connecting Matagorda Island Block 681 to onshore markets. The Partnership
     paid the Apache subsidiary transportation fees totaling $.1 million in each
     of 2000, 1999 and 1998 for the Partnership's share of gas. The fees, which
     are netted against oil and gas sales on the income statement, were at the
     same rates and terms as previously paid to Shell.

         The Partnership's revenues are derived principally from
     uncollateralized sales to customers in the oil and gas industry; therefore,
     customers may be similarly affected by changes in economic and other
     conditions within the industry. The Partnership has not experienced
     material credit losses on such sales.


(6)  FINANCIAL INSTRUMENTS

         The carrying amount of cash and cash equivalents, accrued revenues
     receivables and other financial instruments included in the accompanying
     balance sheet approximated their fair values at December 31, 2000 and 1999.
     The Partnership did not use derivative financial instruments or otherwise
     engage in hedging activities during the three-year period ended December
     31, 2000.



                                       21
<PAGE>   24

                     APACHE OFFSHORE INVESTMENT PARTNERSHIP
                      SUPPLEMENTAL OIL AND GAS DISCLOSURES
                                   (UNAUDITED)


     OIL AND GAS RESERVE INFORMATION -

         Proved oil and gas reserve quantities are based on estimates prepared
     by Ryder Scott Company, L.P., Petroleum Consultants, independent petroleum
     engineers, in accordance with guidelines established by the SEC. These
     reserves are subject to revision due to the inherent imprecision in
     estimating reserves, and are revised as additional information becomes
     available. All the Partnership's reserves are located offshore Texas and
     Louisiana.

         There are numerous uncertainties inherent in estimating quantities of
     proved reserves and projecting future rates of production and timing of
     development expenditures. The following reserve data represents estimates
     only and should not be construed as being exact.

     (Oil in Mbbls and gas in MMcf)

<TABLE>
<CAPTION>
                                                          2000                    1999                    1998
                                                  --------------------    --------------------    ---------------------
                                                    OIL         GAS         OIL         GAS         OIL         GAS
                                                  --------    --------    --------    --------    --------    --------
<S>                                               <C>         <C>         <C>         <C>         <C>         <C>
Proved Reserves

  Beginning of year                                    687       8,992         832      10,269         922      12,511
    Extensions, discoveries and other additions        239         747           4         163           3       2,080
    Revisions of previous estimates                     76         661         (27)      1,684          17        (997)
    Production                                        (119)     (2,320)       (122)     (2,938)       (106)     (3,127)
    Sales of reserves in-place                          --          --          --        (186)         (4)       (198)
                                                  --------    --------    --------    --------    --------    --------

  End of year                                          883       8,080         687       8,992         832      10,269
                                                  ========    ========    ========    ========    ========    ========

Proved Developed

  Beginning of year                                    613       8,679         792       8,585         883      10,824
                                                  ========    ========    ========    ========    ========    ========

  End of year                                          736       7,462         613       8,679         792       8,585
                                                  ========    ========    ========    ========    ========    ========
</TABLE>



                                       22
<PAGE>   25

                     APACHE OFFSHORE INVESTMENT PARTNERSHIP
               SUPPLEMENTAL OIL AND GAS DISCLOSURES - (CONTINUED)
                                   (UNAUDITED)

     FUTURE NET CASH FLOWS -

         The following table sets forth unaudited information concerning future
     net cash flows from proved oil and gas reserves. Future cash inflows are
     based on year-end prices. Operating costs and future development costs are
     based on current costs with no escalation. As the Partnership pays no
     income taxes, estimated future income tax expenses are omitted. This
     information does not purport to present the fair value of the Partnership's
     oil and gas assets, but does present a standardized disclosure concerning
     possible future net cash flows that would result under the assumptions
     used.

     Discounted Future Net Cash Flows Relating to Proved Reserves

<TABLE>
<CAPTION>
                                                        DECEMBER 31,
                                           --------------------------------------
                                              2000          1999          1998
                                           ----------    ----------    ----------
                                                       (In thousands)
<S>                                        <C>           <C>           <C>
        Future cash inflows                $  104,319    $   37,964    $   27,473
        Future production costs                (3,705)       (3,679)       (4,278)
        Future development costs               (5,958)       (3,540)       (4,466)
                                           ----------    ----------    ----------

        Net cash flows                         94,656        30,745        18,729
        10 percent annual discount rate       (29,333)       (9,483)       (5,001)
                                           ----------    ----------    ----------

        Discounted future net cash flows   $   65,323    $   21,262    $   13,728
                                           ==========    ==========    ==========
</TABLE>

         The following table sets forth the principal sources of change in the
discounted future net cash flows:

<TABLE>
<CAPTION>
                                                          FOR THE YEAR ENDED DECEMBER 31,
                                                      --------------------------------------
                                                            2000          1999          1998
                                                      ----------    ----------    ----------
                                                                  (In thousands)
<S>                                                   <C>           <C>           <C>
        Sales, net of production costs                $  (11,884)   $   (7,848)   $   (6,827)
        Net change in prices and production costs         39,718        10,868        (9,548)
        Extensions, discoveries and other additions        7,644           483         2,662
        Development costs incurred                           933           885         1,278
        Revisions of quantities                            6,016         2,919        (1,029)
        Accretion of discount                              2,126         1,373         2,686
        Changes in future development costs               (1,799)           24          (132)
        Sales of reserves in-place                            --          (214)         (192)
        Changes in production rates and other              1,307          (956)       (2,027)
                                                      ----------    ----------    ----------

                                                      $   44,061    $    7,534    $  (13,129)
                                                      ==========    ==========    ==========
</TABLE>



                                       23
<PAGE>   26

ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
        FINANCIAL DISCLOSURE

     None.


                                    PART III


ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE PARTNERSHIP

     All management functions are performed by Apache, the Managing Partner of
the Partnership. The Partnership itself has no officers or directors.
Information concerning the officers and directors of Apache set forth under the
captions "Nominees for Election as Directors", "Continuing Directors",
"Executive Officers of the Company", and "Securities Ownership and Principal
Holders" in the proxy statement relating to the 2001 annual meeting of
shareholders of Apache (the Apache Proxy) is incorporated herein by reference.


ITEM 11. EXECUTIVE COMPENSATION

     See Note (3), "Compensation to Apache" of the Partnership's financial
statements, under Item 8 above, for information regarding compensation to Apache
as Managing Partner. The information concerning the compensation paid by Apache
to its officers and directors set forth under the captions "Summary Compensation
Table", "Option/SAR Grants Table", "Option/SAR Exercises and Year-End Value
Table", "Employment Contracts and Termination of Employment and
Change-in-Control Arrangements", and "Director Compensation" in the Apache Proxy
is incorporated herein by reference.


ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT

     Apache, as an Investing Partner and the General Partner, owns 53 Units, or
4.7 percent of the outstanding Units of the Partnership, as of December 31,
2000. Directors and officers of Apache own 9.7 Units, slightly less than one
percent of the Partnership's Units, as of December 31, 2000. Apache owns a
one-percent General Partner interest (15 equivalent Units). To the knowledge of
the Partnership, no Investing Partner owns, of record or beneficially, more than
five percent of the Partnership's outstanding Units.


ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS

     Effective November 1992, with Apache's and the Partnership's acquisition of
an additional net revenue interest in Matagorda Island Blocks 681 and 682, a
wholly-owned subsidiary of Apache purchased from Shell a 14.4 mile-long natural
gas and condensate pipeline connecting Matagorda Island Block 681 to onshore
markets. The Partnership paid the Apache subsidiary transportation fees totaling
$.1 million in each of 2000, 1999 and 1998 for Partnership's share of gas.

     Apache markets the Partnership's natural gas production through Cinergy
Marketing & Trading, LLC. In June 1998, Apache formed a strategic alliance with
Cinergy to market substantially all of Apache's natural gas production from
North America and sold its 57 percent interest in Producers Energy Marketing LLC
(ProEnergy) to Cinergy. ProEnergy, renamed Cinergy Marketing & Trading, LLC,
will continue to market Apache's North American natural gas production for 10
years, with an option to terminate after six years, under an amended and
restated gas purchase agreement effective July 1, 1998. The prices the
Partnership received for its gas production prior to the sale of ProEnergy were,
in the opinion of Apache, comparable to the prices that would have been received
from a non-affiliated party. The prices the Partnership received after the sale
of ProEnergy and will continue to receive for its gas production, in the opinion
of Apache, approximate market prices.

     During 2000, Apache Crude Oil Marketing, Inc., a wholly-owned subsidiary of
Apache, purchased oil and condensate from the Partnership which accounted for
approximately 12 percent of the Partnership's total oil and gas sales. The
prices the Partnership received for these sales were based on third-party
pricing indexes, and in the opinion of Apache, comparable to prices that would
have been received from a non-affiliated party.



                                       24
<PAGE>   27

                                     PART IV


ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K

  a.(1)  Financial Statements - See accompanying index to financial statements
         in Item 8 above.

    (2)  Financial Statement Schedules - See accompanying index to financial
         statements in Item 8 above.

    (3)  Exhibits

              3.1   Partnership Agreement of Apache Offshore Investment
                    Partnership (incorporated by reference to Exhibit (3)(i) to
                    Form 10 filed by Partnership with the Commission on April
                    30, 1985, Commission File No. 0-13546).

              3.2   Amendment No. 1, dated February 11, 1994, to the Partnership
                    Agreement of Apache Offshore Investment Partnership
                    (incorporated by reference to Exhibit 3.3 to Partnership's
                    Annual Report on Form 10-K for the year ended December 31,
                    1993, Commission File No. 0-13546).

              3.3   Limited Partnership Agreement of Apache Offshore Petroleum
                    Limited Partnership (incorporated by reference to Exhibit
                    (3)(ii) to Form 10 filed by Partnership with the Commission
                    on April 30, 1985, Commission File No. 0-13546).

             10.1   Credit Agreement dated July 24, 1992, between Apache, the
                    Lenders named therein and the First National Bank of
                    Chicago, as Agent (incorporated by reference to Exhibit 10.1
                    to Partnership's Quarterly Report on Form 10-Q for the
                    quarter ended June 30, 1992, Commission File No. 0-13546).

             10.2   Second Amendment, dated as of July 29, 1994, to Credit
                    Agreement between Apache, the Lenders named therein and the
                    First National Bank of Chicago, as Agent (incorporated by
                    reference to Exhibit 10.1 to Partnership's Quarterly Report
                    on Form 10-Q for the quarter ended September 30, 1994,
                    Commission File No. 0-13546).

             10.3   Third Amendment, dated as of March 31, 1995, to the Credit
                    Agreement between Apache, the Lenders named therein and the
                    First National Bank of Chicago, as Agent (incorporated by
                    reference to Exhibit 10.6 to Partnership's Annual Report on
                    Form 10-K for the year ended December 31, 1995, Commission
                    File No. 0-13546).

             10.4   Form of Assignment and Assumption Agreement between Apache
                    Corporation and Apache Offshore Petroleum Limited
                    Partnership (incorporated by reference to Exhibit 10.2 to
                    Partnership's Quarterly Report on Form 10-Q for the quarter
                    ended June 30, 1992, Commission File No. 0-13546).

             10.5   Joint Venture Agreement, dated as of November 23, 1992,
                    between Apache Corporation and Apache Offshore Petroleum
                    Limited Partnership (incorporated by reference to Exhibit
                    10.6 to Partnership's Annual Report on Form 10-K for the
                    year ended December 31, 1992, Commission File No. 0-13546).

             10.6   Matagorda Island 681 Field Purchase and Sale Agreement with
                    Option to Exchange, dated November 24, 1992, between Apache
                    Corporation, Shell Offshore, Inc. and SOI Royalties, Inc.
                    (incorporated by reference to Exhibit 10.7 to Partnership's
                    Annual Report on Form 10-K for the year ended December 31,
                    1992, Commission File No. 0-13546).



                                       25
<PAGE>   28

            *23.1   Consent of Ryder Scott Company, L.P., Petroleum Consultants.

             99.1   Consent statement of the Partnership, dated January 7, 1994
                    (incorporated by reference to Exhibit 99.1 to Partnership's
                    Annual Report on Form 10-K for the year ended December 31,
                    1993, Commission File No. 0-13546).

             99.2   Proxy statement to be dated on or about March 31, 2001,
                    relating to the 2001 annual meeting of shareholders of
                    Apache Corporation (incorporated by reference to the
                    document filed by Apache pursuant to Rule 14A, Commission
                    File No. 1-4300).

                    *Filed herewith.

   b.        Reports filed on Form 8-K.

             No reports on Form 8-K were filed during the fiscal quarter ended
December 31, 2000.



                                       26
<PAGE>   29

                                   SIGNATURES

     Pursuant to the requirements of Section 13 or 15(d) of the Securities
Exchange Act of 1934, the Partnership has duly caused this report to be signed
on its behalf by the undersigned, thereunto duly authorized.

                                       APACHE OFFSHORE INVESTMENT PARTNERSHIP

                                       By: Apache Corporation, General Partner


Date: March  23, 2001                  By: /s/ Raymond Plank
                                          --------------------------------------
                                          Raymond Plank,
                                          Chairman and Chief Executive Officer


                                POWER OF ATTORNEY

     The officers and directors of Apache Corporation, General Partner of Apache
Offshore Investment Partnership, whose signatures appear below, hereby
constitute and appoint Raymond Plank, G. Steven Farris, Z.S. Kobiashvili and
Roger B. Plank, and each of them (with full power to each of them to act alone),
the true and lawful attorney-in-fact to sign and execute, on behalf of the
undersigned, any amendment(s) to this report and each of the undersigned does
hereby ratify and confirm all that said attorneys shall do or cause to be done
by virtue thereof.

     Pursuant to the requirements of the Securities Exchange Act of 1934, this
report has been signed below by the following persons on behalf of the
Partnership and in the capacities and on the dates indicated.

<TABLE>
<CAPTION>
                  SIGNATURE                                       TITLE                              DATE
--------------------------------------------      --------------------------------------      -------------------
<S>                                               <C>                                         <C>
/s/ Raymond Plank                                 Chairman and Chief Executive                   March 23, 2001
--------------------------------------------       Officer (Principal Executive Officer)
Raymond Plank


/s/ Roger B. Plank                                Executive Vice President and Chief             March 23, 2001
--------------------------------------------       Financial Officer (Principal Financial
Roger B. Plank                                     Officer)


/s/ Thomas L. Mitchell                            Vice President and Controller                  March 23, 2001
--------------------------------------------       (Principal Accounting Officer)
Thomas L. Mitchell
</TABLE>



<PAGE>   30

<TABLE>
<CAPTION>
                  SIGNATURE                                        TITLE                              DATE
--------------------------------------------       --------------------------------------      -------------------
<S>                                                <C>                                         <C>
/s/ Frederick M. Bohen                             Director                                       March 23, 2001
--------------------------------------------
Frederick M. Bohen


/s/ G. Steven Farris                               Director                                       March 23, 2001
--------------------------------------------
G. Steven Farris


/s/ Randolph M. Ferlic                             Director                                       March 23, 2001
--------------------------------------------
Randolph M. Ferlic


/s/ Eugene C. Fiedorek                             Director                                       March 23, 2001
--------------------------------------------
Eugene C. Fiedorek


/s/ A. D. Frazier, Jr.                             Director                                       March 23, 2001
--------------------------------------------
A. D. Frazier, Jr.


/s/ John A. Kocur                                  Director                                       March 23, 2001
--------------------------------------------
John A. Kocur


/s/ George D. Lawrence Jr.                         Director                                       March 23, 2001
--------------------------------------------
George D. Lawrence Jr.


/s/ Mary Ralph Lowe                                Director                                       March 23, 2001
--------------------------------------------
Mary Ralph Lowe


/s/ F. H. Merelli                                  Director                                       March 23, 2001
--------------------------------------------
F. H. Merelli


/s/ Rodman D. Patton                               Director                                       March 23, 2001
--------------------------------------------
Rodman D. Patton


/s/ Charles J. Pitman                              Director                                       March 23, 2001
--------------------------------------------
Charles J. Pitman
</TABLE>



<PAGE>   31

                                INDEX TO EXHIBITS

<TABLE>
<CAPTION>
       EXHIBIT
       NUMBER                                  DESCRIPTION
       -------                                 -----------
<S>               <C>
         3.1      Partnership Agreement of Apache Offshore Investment
                  Partnership (incorporated by reference to Exhibit (3)(i) to
                  Form 10 filed by Partnership with the Commission on April 30,
                  1985, Commission File No. 0-13546).

         3.2      Amendment No. 1, dated February 11, 1994, to the Partnership
                  Agreement of Apache Offshore Investment Partnership
                  (incorporated by reference to Exhibit 3.3 to Partnership's
                  Annual Report on Form 10-K for the year ended December 31,
                  1993, Commission File No. 0-13546).

         3.3      Limited Partnership Agreement of Apache Offshore Petroleum
                  Limited Partnership (incorporated by reference to Exhibit
                  (3)(ii) to Form 10 filed by Partnership with the Commission on
                  April 30, 1985, Commission File No. 0-13546).

         10.1     Credit Agreement dated July 24, 1992, between Apache, the
                  Lenders named therein and the First National Bank of Chicago,
                  as Agent (incorporated by reference to Exhibit 10.1 to
                  Partnership's Quarterly Report on Form 10-Q for the quarter
                  ended June 30, 1992, Commission File No. 0-13546).

         10.2     Second Amendment, dated as of July 29, 1994, to Credit
                  Agreement between Apache, the Lenders named therein and the
                  First National Bank of Chicago, as Agent (incorporated by
                  reference to Exhibit 10.1 to Partnership's Quarterly Report on
                  Form 10-Q for the quarter ended September 30, 1994, Commission
                  File No. 0-13546).

         10.3     Third Amendment, dated as of March 31, 1995, to the Credit
                  Agreement between Apache, the Lenders named therein and the
                  First National Bank of Chicago, as Agent (incorporated by
                  reference to Exhibit 10.6 to Partnership's Annual Report on
                  Form 10-K for the year ended December 31, 1995, Commission
                  File No. 0-13546).

         10.4     Form of Assignment and Assumption Agreement between Apache
                  Corporation and Apache Offshore Petroleum Limited Partnership
                  (incorporated by reference to Exhibit 10.2 to Partnership's
                  Quarterly Report on Form 10-Q for the quarter ended June 30,
                  1992, Commission File No. 0-13546).

         10.5     Joint Venture Agreement, dated as of November 23, 1992,
                  between Apache Corporation and Apache Offshore Petroleum
                  Limited Partnership (incorporated by reference to Exhibit 10.6
                  to Partnership's Annual Report on Form 10-K for the year ended
                  December 31, 1992, Commission File No. 0-13546).

         10.6     Matagorda Island 681 Field Purchase and Sale Agreement with
                  Option to Exchange, dated November 24, 1992, between Apache
                  Corporation, Shell Offshore, Inc. and SOI Royalties, Inc.
                  (incorporated by reference to Exhibit 10.7 to Partnership's
                  Annual Report on Form 10-K for the year ended December 31,
                  1992, Commission File No. 0-13546).

         *23.1    Consent of Ryder Scott Company, L.P., Petroleum Consultants.

         99.1     Consent statement of the Partnership, dated January 7, 1994
                  (incorporated by reference to Exhibit 99.1 to Partnership's
                  Annual Report on Form 10-K for the year ended December 31,
                  1993, Commission File No. 0-13546).

         99.2     Proxy statement to be dated on or about March 31, 2001,
                  relating to the 2001 annual meeting of shareholders of Apache
                  Corporation (incorporated by reference to the document filed
                  by Apache pursuant to Rule 14A, Commission File No. 1-4300).
</TABLE>


                  *Filed herewith.